Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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9/3-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    9/3-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    9/3-1
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    A/S Norske Shell
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    525-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    38
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    29.07.1986
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    04.09.1986
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    04.09.1988
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    25.04.2005
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    DRY
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    99.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1971.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    1970.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    77
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    LATE TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 49' 45.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 45' 58.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6411210.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    604894.26
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    921

  • Wellbore history
    General
    Well 9/3-1 was drilled on a salt induced domal trap developed at the edge of the Stavanger Platform. The main objective of the well was to evaluate the sandstones of the Middle Jurassic Vestland Group at a prognosed depth of 1805 m. The well was designed to achieve a valid test of the prospect with one well, and to ensure a satisfactory tie of well results to existing seismic data. The prognosed TD was 2125 m. The well was planned to fully penetrate the reservoir sequence and proceed 50 m deeper than the crest, into the underlying rocks of Triassic age.
    Operations and results
    Wildcat well 9/3-1 was spudded with the semi-submersible installation Borgny Dolphin on 29 July 1986 and drilled to TD at 1972 m in the Triassic Skagerrak Formation. Drilling proceeded without significant problems.
    Top Sandnes Formation came in at 1788 m, 18 m above prognosed depth. The reservoir was water bearing with no trace of hydrocarbons. The Vestland Group was found to be 167 m thick with porosities up to 29.5%. Permeability measurements from the core in the Sandnes Formation gave an average value of about 1000 mD, but as high as 4700 mD in one instance. No increase in background gas and no fluorescence or other hydrocarbon indications were observed on cuttings or on any of the 70 sidewall cores recovered. The Tau Formation shales had excellent source rock properties with TOC in the range 1.5 % to 4.5 % and hydrogen indexes in the range 100 to 500 mg HC/g TOC. Coals of the Lower Sandnes Formation and in the Bryne Formation also showed excellent properties with hydrogen indexes up to 465 mg HC/g TOC. No migrant hydrocarbons were however indicated by the organic geochemical analyses, and all formations penetrated by the well were immature for generation of petroleum and. One core was cut in the interval 1799 -1814 m in the Sandnes Formation. The RFT tool was run in the bottom hole section over the reservoir and 8 good pressure points confirmed a water gradient. No fluid sample was taken.
    The well was permanently abandoned on 4 September 1986 as a dry hole.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    225.00
    1969.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    1798.0
    1805.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    7.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1798-1802m
    Core photo at depth: 1802-1805m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1798-1802m
    1802-1805m

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    204.5
    36
    215.0
    0.00
    LOT
    SURF.COND.
    20
    528.0
    26
    540.0
    1.40
    LOT
    INTERM.
    13 3/8
    1349.0
    17 1/2
    1360.0
    1.80
    LOT
    OPEN HOLE
    1971.0
    12 1/4
    1971.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    230
    1335
    DIL LSS GR
    1350
    1979
    DLL MSFL GR
    1350
    1967
    ISF LSS GR
    204
    540
    ISF LSS GR
    529
    1356
    LDL CNL GR
    204
    540
    LDL CNL GR
    529
    1356
    LDL CNL NGL
    1350
    1971
    RFT
    1801
    1837
    SHDT
    1350
    1972
    SHDT GR
    529
    1354
    VSP
    204
    1970

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.33
    pdf
    1.62

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    0.95
    pdf
    13.30

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    158
    1.03
    WATER BASED
    08.09.1986
    179
    1.03
    WATERBASED
    04.08.1986
    188
    1.03
    WATERBASED
    06.08.1986
    215
    1.03
    WATERBASED
    04.08.1986
    215
    0.00
    WATERBASED
    06.08.1986
    220
    1.03
    9.0
    22.0
    WATERBASED
    06.08.1986
    227
    0.00
    WATER BASED
    03.09.1986
    540
    1.08
    10.0
    30.0
    WATERBASED
    06.08.1986
    540
    0.00
    8.0
    30.0
    WATERBASED
    11.08.1986
    540
    0.00
    10.0
    30.0
    WATERBASED
    11.08.1986
    540
    0.00
    12.0
    30.0
    WATERBASED
    14.08.1986
    540
    0.00
    WATERBASED
    14.08.1986
    545
    1.15
    12.0
    18.0
    WATERBASED
    14.08.1986
    720
    1.15
    13.0
    24.0
    WATERBASED
    14.08.1986
    931
    1.17
    12.0
    23.0
    WATER BASED
    21.08.1986
    1159
    1.20
    12.0
    22.0
    WATER BASED
    21.08.1986
    1210
    1.50
    WATER BASED
    01.09.1986
    1316
    1.21
    13.0
    14.0
    WATER BASED
    21.08.1986
    1360
    1.20
    13.0
    15.0
    WATER BASED
    21.08.1986
    1360
    1.20
    19.0
    18.0
    WATER BASED
    21.08.1986
    1360
    1.20
    18.0
    20.0
    WATER BASED
    21.08.1986
    1360
    1.20
    17.0
    10.0
    WATER BASED
    21.08.1986
    1426
    1.21
    21.0
    17.0
    WATER BASED
    22.08.1986
    1562
    1.20
    15.0
    18.0
    WATER BASED
    22.08.1986
    1610
    1.26
    21.0
    18.0
    WATER BASED
    22.08.1986
    1757
    1.40
    30.0
    24.0
    WATER BASED
    25.08.1986
    1798
    1.42
    30.0
    20.0
    WATER BASED
    25.08.1986
    1810
    1.55
    28.0
    16.0
    WATER BASED
    28.08.1986
    1885
    1.55
    30.0
    18.0
    WATER BASED
    28.08.1986
    1895
    1.55
    34.0
    22.0
    WATER BASED
    28.08.1986
    1914
    1.55
    28.0
    22.0
    WATER BASED
    31.08.1986
    1953
    1.50
    30.0
    27.0
    WATER BASED
    31.08.1986
    1972
    1.50
    28.0
    19.0
    WATER BASED
    31.08.1986
    1972
    1.51
    29.0
    20.0
    WATER BASED
    01.09.1986
    1972
    1.50
    28.0
    19.0
    WATER BASED
    31.08.1986

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    310.0
    [m]
    DC
    RRI
    330.0
    [m]
    DC
    RRI
    350.0
    [m]
    DC
    RRI
    370.0
    [m]
    DC
    RRI
    390.0
    [m]
    DC
    RRI
    410.0
    [m]
    DC
    RRI
    430.0
    [m]
    DC
    RRI
    450.0
    [m]
    DC
    RRI
    470.0
    [m]
    DC
    RRI
    490.0
    [m]
    DC
    RRI
    510.0
    [m]
    DC
    RRI
    530.0
    [m]
    DC
    RRI
    550.0
    [m]
    DC
    RRI
    570.0
    [m]
    DC
    RRI
    590.0
    [m]
    DC
    RRI
    610.0
    [m]
    DC
    RRI